Method And System For Controlling A Well Service Rig Based On Load Data

ABSTRACT

The present invention is directed to methods for controlling the operations of a well service rig at a well site by evaluating load sensor data obtained from sensors on or associated with the well service rig. A rig load data chart can be reviewed and an average rig load can be determined for each pull of tubing or rods from a well. The average rig load can be used to calculate and set a rig overload level. If the rig load sensor reads a rig load at or above the rig overload level, the clutch for the hoist can be disengaged and the brake applied to prevent the load from either damaging the rig or breaking off the tubing or rods in the well. In addition, the rig load can be evaluated to determine when the limit the block speed when pulling rods or tubing.

FIELD OF THE INVENTION

The present invention generally pertains to equipment used for repairingwells that have already been drilled. More specifically the presentinvention pertains to an analysis of rig loads and rig load data todetermine and monitor tubing and/or rod removal overload conditions on awell service rig.

BACKGROUND OF THE INVENTION

After a well has been drilled, it must be completed before it canproduce gas or oil. Once completed, a variety of events may occur to theformation causing the well and its equipment to require a “work-over.”For purposes of this application, “work-over” and “service” operationsare used in their very broadest sense to refer to any and all activitiesperformed on or for a well to repair or rehabilitate the well, and alsoincludes activities to shut in or cap the well. Generally, work-overoperations include such things as replacing worn or damaged parts (e.g.,a pump, sucker rods, tubing, and packer glands), applying secondary ortertiary recovery techniques, such as chemical or hot oil treatments,cementing the wellbore, and logging the wellbore, to name just a few.Service operations are usually performed by or involve a mobilework-over or well service rig (collectively hereinafter “service rig” or“rig”) that is adapted to, among other things, pull the well tubing orrods and also to run the tubing or rods back in to the well. Typically,these mobile service rigs are motor vehicle-based and have anextendible, jack-up derrick complete with draw works and block.

During rod or tubing removal, a rig operator typically lifts a stand oftubing (or rods) which is then held in place by slips (or elevators forrods) while the stand is separated from the remaining portion of thetubing or rod string in the well. Once the stand of tubing has beenseparated from that which is still in the well, the stand of tubing canbe placed on a tubing board. During the initial lifting operation, theweight or load on the hook can fluctuate greatly based on the weight ofthe tubing string in the well, the conditions within the well, thecondition of the tubing string, and the amount of acceleration of thetubing string. In general the tubing string acts similarly to a rubberband. As the operator begins to accelerate the block upward and pull thetubing string out of the well the tubing string initially becomeselongated for a short interval before the entire tubing string begins tomove upward through the well. The same elongation can occur when aportion of the tubing string encounters a part of the well withincreased friction or gets snagged or stuck within a portion of thewell. If the operator does not recognize the problem quickly enough, theamount of load on the hook (“hookload”) can increase very quickly to alevel that is above the safe operating level of the rig. While alarmscan be employed, if the operator cannot act quickly enough, the rig maybe damaged and workers around the well could be injured.

In addition, as the stands of tubing (or rods) are being pulled out ofthe well, the total amount of weight on the string is reduced and thelength of the string is reduced. When there are only a few stands oftubing left in the well, pulling the tubing out at a typical rate ofspeed, for example, six feet per second, can become more dangerousbecause if the tubing snags or drags in the well there is less overallelasticity within the remaining length of tubing, and therefore, lesstime to react to the increase in hookload. This can cause dangerousconditions around the wellhead.

Furthermore, while a stand of tubing (or rods) is being decoupled fromthe remaining string in the well, the operator brings his engine RPM upto drive the tongs that are used to unscrew the tubing from one another.When the previously pulled stand of tubing is fully disengaged from theremaining tubing in the well, the operator engages the clutch for thehoist and lifts the stand of tubing about another foot or two and placesit onto the tubing board. The lifting of the stand of tubing that smalldistance prior to placement on the tubing board can cause a small spikein the rig load recorded at the rig load sensors. Much of this spike iscaused by the acceleration of the block by the operator. Unfortunately,at times, the operator is in a hurry or is not cautious enough and canbegin lifting the stand of tubing before the stand has been fullyunscrewed from the tubing that remains in the well. When this occurs therig load will suddenly and violently increase. The rig load can continueto increase until the stand of tubing breaks free of the final threadsof the tubing at the wellhead. When the stand breaks free anyone in thevicinity of the wellhead is in danger of serious injury.

What is needed is a method and apparatus for evaluating the rig load orhookload of a service rig when removing tubing or rods from a well anddisengaging the clutch for the hoist when the rig load reaches a levelindicative of a problem with the tubing in the well, such as a snag orhang up. Furthermore, what is needed is a method and apparatus forevaluating the rig load or hookload of a tubing or rod string beingremoved from a well and limiting the speed of the block and hoist whenonly a small amount of tubing or rods remains in the well. In addition,what is needed is a method and apparatus for determining when a stand oftubing or rods is being decoupled from tubing or rods remaining in thewell during a pull operation and preventing or limiting the ability forthe block and hoist to lift the stand if the stand is not fullydisengaged from the remaining tubing or rods in the well.

The present invention is directed to solving these as well as othersimilar issues in the well service area.

SUMMARY OF THE INVENTION

The present invention is directed to controlling the operation of a wellservice rig based on rig load data. By removing the need for or limitingthe capabilities of the operator during situations of increased load onthe well service rig the ability to prevent damage to the service rigand injury to the workers around the well head can be improved.Furthermore, by limiting the speed of the well service rig duringperiods where only a small amount of tubing or rods remains to be pulledout of a wellbore, the opportunity for a dangerous situation caused bythe tubing or rod hanging or getting caught up in the wellbore isreduced based on the fact that reaction time is increased at the slowerspeeds.

For one aspect of the present invention, a method for determining theaverage load during the pulling of a stand of rods or tubing can beachieved by monitoring the load data of a well service rig. The loaddata can be received during the removal process from sensors on the wellservice rig that transmit inputs to a computer or monitor on the rig.The computer can calculate the average load during the pull of a standof tubing or rods based on the load data received from sensors. The loaddata can include the hookload or the load of the rig. The upper loadlimit can then be determined based on the computation of the averageload. The upper load limit can be a fixed amount above the average loadfor each pull of a stand of tubing or rods or a percentage of thehookload or rig load. The upper load limit can then be set for the nextpull of a stand of pipe from the well. The pipe can include, but is notlimited to, pipe, well casing, rods, tubing, or other tubulars.

For another aspect of the present invention, a method for determiningwhen to reduce or limit block and/or hoist speed during a pullingoperation can be achieved based on an evaluation of hook load data. Loaddata can be received from sensors on the well service rig related toload calculations taken during the removal of a pipe string from a well.The hookload or rig load can be calculated based on the load data. Anevaluation of the hookload or rig load can be conducted to determine ifthe load has fallen to or below a certain level. That level can beindicative that the weight of the remaining pipe string in the well ismuch less than when the pull operation first began. If the load is belowa certain level, the speed of the block or the hoist can be limited toan speed that is substantially slower than the normal operation of theblock and hoist during a standard pulling operation. The reduced speedcan increase reaction time in case the pipe string becomes caught in thewell.

For still another aspect of the present invention, a method forpreventing a well service rig from pulling a stand of pipe away from apipe string while the stand of pipe is still engaged with the threads ofthe pipe string can be achieved based on an evaluation of rig load orhookload data. The system can receive information indicating that therig is disengaging a stand of pipe from a pipe string, such as throughthe use of tongs. Load data, such as rig load or hookload data can bereceived when the stand of pipe is being disengaged from the pipestring. An evaluation of the load data can be conducted to determine ifthe load data has increased above a certain level that is indicative ofa stand of pipe being pulled up before the de-threading process hasoccurred from the pipe string. If the load level has increased to orabove a certain level, the clutch for the drive system that is raisingthe stand of pipe can be disengaged automatically or the throttle can bereduced to prohibit over pulling.

BRIEF DESCRIPTION OF DRAWINGS

For a more complete understanding of the exemplary embodiments of thepresent invention and the advantages thereof, reference is now made tothe following description in conjunction with the accompanying drawingsin which:

FIG. 1 is a side view of an exemplary mobile repair unit with itsderrick extended according to one exemplary embodiment of the presentinvention;

FIG. 2 is a side view of the exemplary mobile repair unit with itsderrick retracted according to one exemplary embodiment of the presentinvention;

FIG. 3 is an electrical schematic of a monitor circuit according to oneexemplary embodiment of the present invention;

FIG. 4 is an exemplary end view of an imbalanced derrick according toone exemplary embodiment of the present invention;

FIG. 5 illustrates the raising and lowering of an inner tubing stringwith an exemplary mobile repair unit according to one exemplaryembodiment of the present invention;

FIG. 6 illustrates one embodiment of an activity capture methodologyoutlined in tabular form according to one exemplary embodiment of thepresent invention;

FIG. 7 provides a frontal view of an exemplary operator interfaceaccording to one exemplary embodiment of the present invention;

FIG. 8 is a flowchart of an exemplary process for identifying a rig loador hookload over limit event according to one exemplary embodiment ofthe present invention;

FIG. 9 is an exemplary display of a rig load data chart for determiningrig load and/or hookload on a mobile repair unit according to oneexemplary embodiment of the present invention;

FIG. 10 is a flowchart of an exemplary process for determining theaverage rig load and/or hookload of a tubing string based on anevaluation of the rig load data chart according to one exemplaryembodiment of the present invention;

FIG. 11 is an exemplary display of a portion of the rig load data chartfor a single pull of tubing used to determine the average rig loadand/or hookload of the tubing string in accordance with the exemplaryembodiment of FIG. 10.

FIG. 12 is a flowchart of an exemplary process for determining the rigload and/or hookload limit based on an evaluation of the rig load datachart according to one exemplary embodiment of the present invention;

FIG. 13 is an exemplary display of the rig load data chart incorporatingthe average hookload and hookload limit in accordance with one exemplaryembodiment of the present invention;

FIG. 14 is a flowchart of an exemplary process for limiting block speedduring tubing removal by evaluating the exemplary rig load data chartsaccording to one exemplary embodiment of the present invention; and

FIG. 15 is a flowchart of an exemplary process for preventing the pullof a stand of tubing before the tubing has been disengaged from theremaining tubing in the wellbore according to one exemplary embodimentof the present invention.

DETAILED DESCRIPTION OF THE EXEMPLARY EMBODIMENTS

Exemplary embodiments of the invention will now be described in detailwith reference to the included figures. The exemplary embodiments aredescribed in reference to how they might be implemented. In the interestof clarity, not all features of an actual implementation are describedin this specification. Those of ordinary skill in the art willappreciate that in the development of an actual embodiment, severalimplementation-specific decisions must be made to achieve the inventors'specific goals, such as compliance with system-related andbusiness-related constraints which can vary from one implementation toanother. Moreover, it will be appreciated that such a development effortmight be complex and time-consuming, but would nevertheless be a routineundertaking for those of ordinary skill in the art having benefit ofthis disclosure. Further aspects and advantages of the various figuresof the invention will become apparent from consideration of thefollowing description and review of the figures.

Referring to FIGS. 1 and 5, a retractable, self-contained mobile repairunit 20 is shown to include a truck frame 22 supported on wheels 24, anengine 26, a hydraulic pump 28, an air compressor 30, a firsttransmission 32, a second transmission 34, a variable speed hoist 36, ablock 38, an extendible derrick 40, a first hydraulic cylinder 42, asecond hydraulic cylinder 44, a first transducer 46, a monitor 48, andretractable feet 50.

The engine 26 selectively couples to the wheels 24 and the hoist 36 byway of the transmissions 34 and 32, respectively. The engine 26 alsodrives the hydraulic pump 28 via the line 29 and the air compressor 30via the line 31. The compressor 30 powers a pneumatic slip (Not Shown),and pump powers a set of hydraulic tongs (Not Shown). The pump 28 alsopowers the cylinders 42 and 44 which respectively extend and pivot thederrick 40 to selectively place the derrick 40 in a working position, asshown in FIG. 1, and in a lowered position, as shown in FIG. 2. In theworking position, the derrick 40 is pointed upward, but its longitudinalcenterline 54 is angularly offset from vertical as indicated by theangle 56. The angular offset provides the block 38 access to a wellbore58 without interference with the derrick pivot point 60. With theangular offset 56, the derrick framework does not interfere with thetypically rapid installation and removal of numerous inner pipe segments(known as pipe, inner pipe string, rods, or tubing 62, hereinafter“tubing” or “rods”).

Individual pipe segments (of string 62) and sucker rods are screwed tothemselves using hydraulic tongs. The term “hydraulic tongs” used hereinand below refer to any hydraulic tool that can screw together two pipesor sucker rods. An example would include those provided by B. J. Hughescompany of Houston, Tex. In operation, the pump 28 drives a hydraulicmotor (Not Shown) forward and reverse by way of a valve. Conceptually,the motor drives the pinions which turn a wrench element relative to aclamp. The element and clamp engage flats on the mating couplings of asucker rod or inner pipe string 62 of one conceived embodiment of theinvention. However, it is well within the scope of the invention to haverotational jaws or grippers that clamp on to a round pipe (i.e., noflats) similar in concept to a conventional pipe wrench, but withhydraulic clamping. The rotational direction of the motor determinesassembly or disassembly of the couplings.

While not explicitly shown in the figures, when installing the tubingsegments 62, the pneumatic slip is used to hold the tubing 62 while thenext segment of tubing 62 is screwed on using tongs. A compressor 30provides pressurized air through a valve to rapidly clamp and releasethe slip. A tank helps maintain a constant air pressure. Pressure switchprovides monitor 48 (FIG. 3) with a signal that indirectly indicatesthat rig 20 is in operation.

Referring back to FIG. 1, weight applied to the block 38 is sensed byway of a hydraulic pad 92 that supports the weight of the derrick 40.The hydraulic pad 92 is basically a piston within a cylinder(alternatively a diaphragm) such as those provided M. D. Totco companyof Cedar Park, Tex. Hydraulic pressure in the pad 92 increases withincreasing weight on the block 38. In FIG. 3, the first transducer 46converts the hydraulic pressure to a 0-5 VDC signal 94 that is conveyedto the monitor 48. Alternatively, the first transducer 46 can convertthe hydraulic pressure into a 4-20 milliamp signal. The monitor 48converts signal 94 to a digital value, stores it in a memory 96,associates it with a real time stamp, and eventually communicates thedata to a remote computer 100 or the computer 705, of FIG. 7, by way ofhardwire, a modem 98, T1 line, WiFi or other device or method fortransferring data known to those of ordinary skill in the art.

In the embodiment of FIG. 4, two pads 92 associated with two transducers46 and 102 are used. An integrator 104 separates the pads 92hydraulically. The rod side of the pistons 106 and 108 each have apressure exposed area that is half the full face area of the piston 108.Thus, the chamber 110 develops a pressure that is an average of thepressures in the pads 92. One type of integrator 104 is provided by M.D. Totco company of Cedar Park, Tex. In one embodiment of the presentinvention, just one transducer 46 is used and it is connected to theport 112. In another embodiment of the present invention, twotransducers 46 and 102 are used, with the transducer 102 on the rightside of the rig 20 coupled to the port 114 and the transducer 46 on theleft side coupled to the port 116. Such an arrangement allows one toidentify an imbalance between the two pads 92. While the foregoing hasdescribed the use of a pad 92 to determine load data, those of ordinaryskill in the art will recognize that other types of load gauges can beused, including, but not limited to, strain gauges, line indicators andthe like.

Returning to FIG. 3, transducers 46 and 102 are shown coupled to themonitor 48. The transducer 46 indicates the pressure on the left pad 92and the transducer 102 indicates the pressure on the right pad 92. Agenerator 118 driven by the engine 26 provides an output voltageproportional to the engine speed. This output voltage is applied acrossa dual-resistor voltage divider to provide a 0-5 VDC signal at point 120and then passes through an amplifier 122. A generator 118 representsjust one of many various tachometers that provide a feedback signalproportional to the engine speed. Another example of a tachometer wouldbe to have engine 26 drive an alternator and measure its frequency. Thetransducer 80 provides a signal proportional to the pressure ofhydraulic pump 28, and thus proportional to the torque of the tongs.

A telephone accessible circuit 124, referred to as a “POCKET LOGGER” byPace Scientific, Inc. of Charlotte, N.C., includes four input channels126, 128, 130 and 132; a memory 96 and a clock 134. The circuit 124periodically samples inputs 126, 128, 130 and 132 at a user selectablesampling rate; digitizes the readings; stores the digitized values; andstores the time of day that the inputs were sampled. It should beappreciated by those skilled in the art that with the appropriatecircuit, any number of inputs can be sampled and the data could betransmitted instantaneously upon receipt.

A supervisor at a computer 100 remote from the work site at which theservice rig 20 is operating accesses the data stored in the circuit 124by way of a PC-based modem 98 and a cellular phone 136 or other knownmethods for data transfer. The phone 136 reads the data stored in thecircuit 124 via the lines 138 (RJ11 telephone industry standard) andtransmits the data to the modem 98 by way of antennas 140 and 142. In analternative embodiment the data is transmitted by way of a cable modemor WiFi system (Not Shown). In one exemplary embodiment of the presentinvention, the phone 136 includes a CELLULAR CONNECTION™ provided byMotorola Incorporated of Schaumburg, Ill. (a model S1936C for Series IIcellular transceivers and a model S1688E for older cellulartransceivers).

Some details worth noting about the monitor 48 is that its access by wayof a modem makes the monitor 48 relatively inaccessible to the crew atthe job site itself. However the system can be easily modified to allowthe crew the capability to edit or amend the data being transferred. Theamplifiers 122, 144, 146 and 148 condition their input signals toprovide corresponding inputs 126, 128, 130 and 132 having an appropriatepower and amplitude range. Sufficient power is needed for RC circuits150 which briefly (e.g., 2-10 seconds) sustain the amplitude of inputs126, 128, 130 and 132 even after the outputs from transducers 46, 102and 80 and the output of the generator 118 drop off. This ensures thecapturing of brief spikes without having to sample and store anexcessive amount of data. A DC power supply 152 provides a clean andprecise excitation voltage to the transducers 46, 102 and 80; and alsosupplies the circuit 124 with an appropriate voltage by way of a voltagedivider 154. A pressure switch 90 enables the power supply 152 by way ofthe relay 156, whose contacts 158 are closed by the coil 160 beingenergized by the battery 162. FIG. 5 presents an exemplary displayrepresenting a service rig 20 lowering an inner pipe string 62 asrepresented by arrow 174 of FIG. 5.

FIG. 6 provides an illustration of an activity capture methodology intabular form according to one exemplary embodiment of the presentinvention. Now referring to FIG. 6, an operator first chooses anactivity identifier for his/her upcoming task. If “GLOBAL” is chosen,then the operator would choose from rig up/down, pull/run tubing orrods, or laydown/pickup tubing and rods (options not shown in FIG. 6).If “ROUTINE: INTERNAL” is selected, then the operator would choose fromrigging up or rigging down an auxiliary service unit, longstroke, cutparaffin, nipple up/down a BOP, fishing, jarring, swabbing, flowback,drilling, clean out, well control activities such as killing the well orcirculating fluid, unseating pumps, set/release tubing anchor,set/release packer, and pick up/laydown drill collars and/or othertools. Finally, if “ROUTINE: EXTERNAL” is chosen, the operator wouldthen select an activity that is being performed by a third party, suchas rigging up/down third party servicing equipment, well stimulation,cementing, logging, perforating, or inspecting the well, and othercommon third party servicing tasks. After the activity is identified, itis classified. For all classifications other than “ON TASK: ROUTINE,” avariance identifier is selected, and then classified using the varianceclassification values.

FIG. 7 provides a view of an rig operator interface or supervisorinterface according to one exemplary embodiment of the presentinvention. Now referring to FIG. 7, all that is required from theoperator is that he or she input in the activity data into a computer705. The operator can interface with the computer 705 using a variety ofmeans, including typing on a keyboard 725 or using a touch-screen 710.In one embodiment, a display 710 with pre-programmed buttons, such aspulling rods or tubing from a wellbore 715, is provided to the operator,as shown in FIG. 7, which allows the operator to simply select theactivity from a group of pre-programmed buttons. For instance, if theoperator were presented with the display 710 of FIG. 7 upon arriving atthe well site, the operator would first press the “RIG UP” button. Theoperator would then be presented with the option to select, for example,“SERVICE UNIT,” “AUXILIARY SERVICE UNIT,” or “THIRD PARTY.” The operatorthen would select whether the activity was on task, or if there was anexception, as described above. In addition, as shown in FIG. 7, prior topulling (removing) 715 or running (inserting) tubing 62, the operatorcould set the high and low limits for the block 38 by pressing the learnhigh or learn low buttons after moving the block 38 into the properposition.

Processes of exemplary embodiments of the present invention will now bediscussed with reference to FIGS. 8, 10, 12, 14, and 15. Certain stepsin the processes described below must naturally precede others for thepresent invention to function as described. However, the presentinvention is not limited to the order of the steps described if suchorder or sequence does not alter the functionality of the presentinvention in an undesirable manner. That is, it is recognized that somesteps may be performed before or after other steps or in parallel withother steps without departing from the scope and spirit of the presentinvention.

Turning now to FIG. 8, a logical flowchart diagram illustrating anexemplary method 800 for identifying an over load limit event on aservice rig 20 based on an evaluation of the rig load data chart ispresented according to one exemplary embodiment of the presentinvention. Referring to FIGS. 1, 3, 5, 7, 8, and 9, the exemplary method800 begins at the START step and continues to step 805, where an inquiryis conducted to determine if the drum clutch for the variable speedhoist 36 is engaged. If the clutch is not engaged, the “NO” branch isfollowed back to step 805 until a determination is made that the clutchis engaged. Otherwise, the “YES” branch is followed to step 810.

In step 810, an inquiry is conducted to determine if the rig load weightis above the baseline weight or load level. The baseline weight isgenerally at a level that is marginally above the weight of the rigitself. In one exemplary embodiment, the baseline weight isapproximately 40,000 pounds. However, those of skill in the art willrecognize that this amount may be easily changed based on other factors,such as rig size, well conditions, etc. In an alternative embodiment,there may not be a need for an evaluation of the baseline weight, as anyrig load limit weight will generally be above the baseline weight. Ifthe weight is not above the baseline weight, the “NO” branch is followedback to step 805. On the other hand, if the rig load weight is above thebaseline weight, the “YES” branch is followed to step 815.

In step 815, an inquiry is conducted to determine if the blocks 38 aremoving in the direction to remove tubing 62 from the wellbore 58. In oneexemplary embodiment, the direction of the blocks 38 can be analyzed bypositioning an encoder (Not Shown) at the hoist 36 or at anotherposition along the line coupled to the block 38. If the block 38 is notmoving in the direction for removing the tubing 62, the “NO” branch isfollowed to step 805. Otherwise, the “YES” branch is followed to step820.

In step 820, an inquiry is conducted to determine if the slips at thewellhead 68 are open. The slips are used when pulling tubing 62 out ofthe well 58. When the tubing 62 is being pulled out and it is time tounscrew one stand of tubing 62 from another, the tubing 62 is set on theslips, which suspend the remaining tubing 62 at the wellhead 186 anddown in the wellbore 58. In one exemplary embodiment, the slips areengaged into position through the use of pneumatic pressure. IN thisexemplary embodiment, the position of the slips can be determinedthrough the use of a pneumatic switch that sense if opening or closingair pressure is being applied to the slips. In an alternativeembodiment, the position of the slips can be evaluated using a slipsensor to evaluate and open/closed position. In this embodiment, theslip sensor can include a pressure-type input/output switch. Those ofordinary skill in the art will recognize that other methods of determinethe position of the slips can also be employed, including photoeyes,proximity sensors and other positional indicators. If the slips are notopen, the “NO” branch is followed to step 805. If the slips are open,the “YES” branch is followed to step 825.

In step 825, the rig load weight data is recorded and displayed at thecomputer 705. FIG. 9 is an illustration of an exemplary display 900 of arig load data chart presenting the rig load weight data and used fordetermining the rig load of a mobile repair unit 20. Referring to FIG.9, the exemplary display 900 includes a rig load data chart 905. TheX-axis of the rig load data chart 905 represents time and the Y-axisrepresents rig load in pounds. Rig load can be measured at severalplaces on the rig 20. For instance, rig load can be measured on eachindividual rig pad 92, on a transducer or sensor on the output side ofthe integrator on the pad weight indicator (Not Shown), on a strain gageplaced on the mast of the rig 20 to measure compression in a derrickleg, on a dead line, line sensor, line diaphragm, sending diaphragm orcylinder (Not Shown). The rig load displayed in the rig load chart 905is based on the total weight on the pads 92, not the load on the hook 38(“hookload”).

FIG. 9 presents the general patterns for rig load data curves duringactivities for pulling rods and tubing 62 out of a wellbore 58. The rigload chart 905 includes a series of rig load data points represented asa weight curve 910. While it appears from the weight curve 910 that therig load data points are being recorded on a constant basis, it ispossible to take the data points at intervals and generate the linebased on averages over a period of data points. The rig load chart 905presents data such as the weight of the rig 20, which can be determinedby evaluating the valleys 915 of the data points. The chart 905 alsopresents spikes 920 of the rig load level. The amount of the spike 920can be based on several factors, including, but not limited to, thespeed at which the tubing 62 is being removed from the well 58,anomalies or wear within the wellbore 58, or problems with the tubing 62in the wellbore 58. While some spiking of the weight data along theweight cure 910 is expected, if the spikes of load data is above certainpredetermined levels, the higher than normal rig load levels canindicate that the tubing 62 is caught or stuck in the wellbore 58, thereare problems with the wellbore 58, the operator is trying to remove thetubing 62 too quickly, and/or further pulling could damage the rig 20 orinjure the workers once the tubing 62 “breaks loose” or the tubing 62breaks off of the tubing string 62.

Returning to FIG. 8, the computer 705 determines the average weight ofthe rig load based on the data in the rig load chart 905 in step 830. Instep 835, the computer 705 determines the rig load limit. In oneexemplary embodiment, the rig load limit is the amount of load above theaverage weight of the rig load that the rig 20 can pull and stilloperate safely. For example, as long as the actual load received at thesensors 92 does not exceed the rig load limit, the rig 20 can continueto operate. However, if the sensors 92 read a load that is greater thanor equal to the rig load limit, the pulling of the tubing 62 can bestopped by disengaging the clutch for the hoist 36. In one exemplaryembodiment, the rig load limit is a constant value above the averageweight for the rig load, for example a value between five and fiftythousand pounds. In another exemplary embodiment, the rig load limit isa percentage of the average rig load for the prior tubing pull that isadded to that average rig load, for example between 1-50 percent. In yetanother exemplary embodiment, the rig load limit is a percentage of thehookload that is added to the average rig load for the prior tubingpull, for example between 1-500% of the hookload. In this embodiment,the hookload can be determined by subtracting the rig weight on its ownfrom the average rig load. The value of the rig weight on its own may beknown, or may be determined by taking the value at the valley 915 of thedata curve 910 for one of the prior tubing pulls.

In step 840, an inquiry is conducted to determine if the rig load levelis above the rig load limit. The current rig load level may bedetermined at the sensor 92 or by monitoring the data curve 910 on thechart 905. If the rig load level is not above the rig load limit, the“NO” branch is followed back to step 825 to continue recording rig loaddata at the computer 705. However, if the rig load level is above therig load limit, the “YES” branch is followed to step 845, where thecomputer 705 sends a signal to apply the brake and disengage the clutchof the hoist 36 and reduce the engine throttle or any combinationthereof, thereby stopping any additional pulling of the tubing 62 out ofthe wellbore 58. In step 850, the computer 705 sends a signal toactivate an alarm and records the overload event for subsequent analysisand training of the rig operator. The alarm may be audible, visual orboth. Audible alarms include, but are not limited to, sirens, horns andthe like. Visual alarms may include, but are not limited to, flashinglights, a light turning on, or a display of a message at the computer705. The process then continues to the END step.

FIG. 10, is a logical flowchart diagram illustrating the exemplarymethod 830 for determining the average rig load based on an evaluationof the rig load data chart 905 according to one exemplary embodiment ofthe present invention. Now referring to FIGS. 1, 5, 7, 8, 9, 10, and 11,the exemplary method 830 begins at step 1005, where a determination ismade as to the start time for pulling a stand of tubing 62. In oneexemplary embodiment, the start time for pulling is determined to bewhen the clutch of the hoist 36 is engaged, the weight is above thebaseline weight, the block 38 is moving upward, and the slips are open,however, fewer than all of these elements and/or different elements maybe analyzed to determine the start time of the pull.

A determination is made as to when the completion time for pulling astand of tubing 62 has occurred in step 1010. In one exemplaryembodiment, the time of completion occurs after the start time when theslips are closed. The time to pull a stand of tubing 62 generally takesapproximately twelve seconds; however, shorter and longer periods arewithin the scope of this invention. FIG. 11, presents the a display 1100of the general pattern for a rig load data curve 1110 while pulling asingle stand of tubing 62 from the starting point to the completionpoint from the wellbore 58. FIG. 11 also includes a static expectedweight curve 1110 superimposed onto the rig load data curve 1105. Thestatic expected weight curve 1110 is a best case scenario for loadgenerated at the rig load sensors 92 during the pulling of a stand oftubing 62. The rig load data curve 1105 can be divided into multipleintervals, in order to separate good data from data containing a largeamount of error. In one exemplary embodiment, the rig load data 1105 canbe divided up into three intervals: the first interval 1115, the secondinterval 1120, and the third interval 1125; however, greater or fewerintervals are within the scope of this invention.

During the first interval 1115, the curve 1105 is reflective of Hooke'slaw, or the spring action of the tubing 62. If the operator pulls offthe slips too fast or has a running start before the elevators engagethe tubing collar, the peak at point 1105 will increase above the actualweight due to momentum. Additionally, not allowing the hoist chainsprocket and right angle drive (Not Shown) to come to a stop prior toengaging the clutch for the hoist 36 will cause the peak at 1105 toincrease as well. In one exemplary embodiment, the first time intervalwill be between one and five seconds, however adjustments to theinterval length may be made based on the length of tubing 62 remainingon the string, the amount of acceleration, and the condition of thewellbore 58. The second interval 1120 is the most reflective of the truerig load. The slope of the rig load data curve 1105 during the secondinterval 1120 is normally positive because the block speed isincreasing, however, the slope can be zero if the block speed isconstant. The third interval 1125 is the interval with the fastestascending tubing 62 speed. The data 1105 during the third interval canbe reflective of swabbing the hole. The increase in the apparent weightduring the third interval 1125 is typically due to drag and speed of thetubing 62.

Returning to FIG. 10, the rig load data from the first interval 1115, orfirst predetermined amount of time, after the beginning of the pull ofthe tubing string 62 is removed from the average rig load analysis instep 1015. In one exemplary embodiment, the first predetermined amountof time is between one and five seconds. In an alternative embodiment,the first predetermined amount of time is a percentage of the entiretime period to pull a single stand of tubing 62 from the start point tothe completion point. In this exemplary embodiment, the percentage canbe between 1-40 percent of the entire time period. In step 1020, the rigload data for the second predetermined amount of time, or third interval1125, is removed from the analysis of the average rig load. If the thirdinterval is a specific amount of time, in one example between one andfive seconds, the data removed will be determined from the completionpoint for the string pull and working backwards from there. However, inan alternative embodiment, the third interval 1125 can be a percentageof the overall time period to pull the stand of tubing 62. In thisexemplary embodiment, the percentage can be between 1-40 percent of theentire time period. In step 1025, the computer 705 averages theremaining rig load data 1105 to determine an average rig load. In oneexemplary embodiment, the remaining rig load data includes only the data1105 plotted during the second interval 1120. The process then continuesto step 835 of FIG. 8.

FIG. 12, is a logical flowchart diagram illustrating the exemplarymethod 835 of FIG. 8 for determining the rig load limit based on anevaluation of the rig load data chart 905 according to one exemplaryembodiment of the present invention. Now referring to FIGS. 1, 5, 7, 8,9, 11, and 12 the exemplary method 835 begins at step 1105, where theaverage rig load is received. In one exemplary embodiment, the averagerig load is determined by the computer 705; however, the average rigload can be manually entered into the computer 705 by the operator ofthe rig 20.

The average rig load is reduced by the weight of the rig 20 in step1210. In one exemplary embodiment, the weight of the rig can bedetermined prior to pulling the tubing 62 or, manually input by the rigoperator. In another exemplary embodiment, the rig weight can bedetermined by receiving the minimum rig load data point 915 of FIG. 9,on the prior pull of a stand of tubing 62 and that amount can bededucted from the average rig load to determine the hookload or weightof tubing 62 in the tubing string 62. In step 1215, an additional loadamount is determined. In one exemplary embodiment, the additional loadamount is a consistent amount of weight, for example, between fivethousand and fifty thousand pounds. In another exemplary embodiment, theamount of additional load is based on a predetermined percentage of thehookload, for example between 1 and 500 percent of the hookload. In yetanother exemplary embodiment, the amount of additional load is based ona predetermined percentage of the average rig load, for example between1-50 percent of average rig load. In this exemplary embodiment, sincethe additional load is based on the average rig load, there is no needto determine the weight of the rig or to subtract the weight of the rigfrom the average rig load. In each of these embodiments, the additionalload can be considered a load safety factor.

In step 1220, the load safety factor is added to the average rig loadfor the most recent pull of a stand of tubing 62. The sum of the loadsafety factor and the average rig load are set as the rig load limit forthe pull of the next stand of tubing 62. The process continues for eachsubsequent stand of tubing 62 until all of the tubing 62 has beenremoved from the wellbore 58. The process continues from step 1225 tostep 840 of FIG. 8.

FIG. 13 is an illustration of an exemplary display 1300 of a rig loaddata chart 1305 presenting the general patterns for exemplary rig loaddata curves at the computer 705 while stands of tubing 62 are beingremoved from the wellbore 58 in accordance with one exemplary embodimentof the present invention. Now referring to FIGS. 9, 10, 12, and 13, theexemplary display 1300 includes a rig load data chart 1305 substantiallyas described with regards to FIG. 9. The rig load data chart includesrig load data 1310 presented as a data curve; however, those of ordinaryskill in the art will recognize that the data 1310 could also beindividual points plotted on a graph without connection in the manner ofa curve. The chart 1305 also includes a series of data points 1320,substantially shown in the shape of a straight line, representing theaverage rig load determined generally as described in FIG. 10.Furthermore, the chart 1305 includes a series of data points 1315,substantially presented in the shape of a straight line, representingthe rig load limit, which is determined as generally described in FIG.12. By superimposing the average rig load 1320 and the rig load limit1315 onto the chart 1305 of rig load data 1310 an operator can betterdetermine the number of times that he has pushed the rig load over therig load limit 1315.

FIG. 14 is a logical flowchart diagram illustrating an exemplary method1400 for limiting block speed during tubing 62 removal by evaluating theexemplary rig load data in the rig load data chart according to oneexemplary embodiment of the present invention. Referring to FIGS. 1, 5,7, 8, 10, and 14, the exemplary method 1400 begins at the START step andcontinues to step 1405, where the computer 705 receives notificationthat the rig 20 is pulling out of the wellbore 58 with tubing 62. Thenotification can take the form of steps 805-820 of FIG. 8. In anotherexemplary embodiment, the notification can be based on the rig operatorselecting the pull activity 715 at the computer 705.

The average rig load is determined in step 830 and is described ingreater detail in FIG. 10. In step 1415, the computer 705 receives theaverage rig load for the most recent pull of a stand of tubing 62. Instep 1420, an inquiry is conducted to determine if the average rig loadhas reached a predetermined level. In one exemplary embodiment, once thetubing string 62 becomes light enough, the risk of catastrophic eventsdue to pulling the string of tubing 62 out of the wellbore 58 tooquickly greatly increases. In one exemplary embodiment, thepredetermined level can be set at a hookload of between one and fiftythousand pounds. The hookload can be added to the known or expectedweight of the rig 20 to insert the predetermined level as a rig load,for example approximately 42,500 pounds in the example of FIG. 9(hookload of 5000 pounds plus rig weight of 37,500 pounds).Alternatively, the computer 705 can determine the average hookloadduring each tubing pull by subtracting the rig weight from the averagerig load and can compare the average hookload to the predetermined levelof hookload.

If the average rig load has not reached a predetermined level, then the“NO” branch is followed to step 1425, where additional stands of tubing62 are removed with the operator having the complete range of speedcontrol available. The process then returns to step 830 to determine theaverage rig load for the most current tubing pull. If the average rigload has reached the predetermined level, then the “YES” branch isfollowed to step 1430, where the computer 705 transmits a signal tolimit block speed while pulling the remaining stands of tubing 62. Thesignal generally acts as a governor for the drive of the hoist 36. Inone exemplary embodiment, the standard speed for removal of tubing 62 isapproximately six feet per second and the limited block speed has amaximum of anywhere between one-half and four feet per second after thepredetermined rig load is reached. In step 1435, the slippage in thetransmission 32 can also be increased for the hoist 36. In one exemplaryembodiment, the slippage in the transmission 32 can be increased byopening a solenoid valve (Not Shown) on the first transmission 32 casethereby relieving hydraulic pressure in the transmission lockup system.The reduction in hydraulic pressure induces slippage into the firsttransmission 32 and thereby offers another level of safety in case therig 20 pulls tubing 62 that unexpectedly gets hung up on something inthe wellbore 58. Additionally, the air pressure applied to the hoistclutch bladder can be reduced, thereby inducing slippage in the hoistclutch. In one exemplary embodiment, the clutch bladder generally isprovided with an air pressure in excess of one hundred pounds per squareinch when a hoist 36 is operating normally with a load. This airpressure can be reduced to induce the slippage described above andprovide another level of safety in case the tubing 62 is hung up in thewellbore 58. The process then continues to the END step. While thepresent method has been described generally in terms of the rig load,those of ordinary skill in the art will recognize that, with minormodifications as discussed herein, the hookload could be substituted forthe rig load in most instances.

FIG. 15 is a logical flowchart diagram illustrating an exemplary method1500 for preventing the pull of a stand of tubing 62 before the tubing62 has been disengaged from the remaining tubing 62 in the wellbore 58according to one exemplary embodiment of the present invention.Referring to FIGS. 1, 5, 7, 9, and 15, the exemplary method 1500 beginsat the START step and continues to step 1505, where an inquiry isconducted to determine if the clutch of the first transmission 32driving the variable speed hoist 36 is engaged. If the clutch is notengaged, the “NO” branch is followed back to step 1505 until adetermination is made that the clutch is engaged. Otherwise, the “YES”branch is followed to step 1510.

In step 1510, an inquiry is conducted to determine if the rig loadweight is above the baseline level. The baseline weight is generally ata level that is marginally above the weight of the rig 20 itself. In oneexemplary embodiment, the baseline weight is approximately 40,000pounds. However, those of skill in the art will recognize that thisamount may be easily changed based on other factors, as described above.In an alternative embodiment, there may not be a need for an evaluationof the baseline weight, as any rig load limit weight will generally beabove the baseline weight. If the weight is not above the baselineweight, the “NO” branch is followed back to step 1505. On the otherhand, if the rig load weight is above the baseline weight, the “YES”branch is followed to step 1515.

In step 1520, an inquiry is conducted to determine if the blocks 38 aremoving in the direction to remove tubing 62 from the wellbore 58. In oneexemplary embodiment, the direction of the blocks 38 can be analyzed bypositioning an encoder at the hoist 36 or at another position along theline coupled to the block 38. If the block 38 is not moving in thedirection for removing the tubing 62, the “NO” branch is followed tostep 1505. Otherwise, the “YES” branch is followed to step 1520. In step1520, an inquiry is conducted to determine if the slips (Not Shown) atthe wellhead 186 are closed during a tubing pull or if the elevator (NotShown) is in use during a rod pull. If the slips are open or theelevator is not in use for the rod pull, the “NO” branch is followed tostep 1505. Otherwise, the “YES” branch is followed to step 1525.

In step 1525, the computer 705 evaluates the rig load data. The computer705 can evaluate the raw data from the sensor 92, data that has been“cleansed,” or it can review the data points on the chart 905. In step1530, an inquiry is conducted to determine if the rig load is above apredetermined level. In one exemplary embodiment, the predeterminedlevel is a hookload of between two and ten thousand pounds or a rig loadhaving a predetermined level of between two and ten thousand pounds plusthe weight or estimated weight of the rig 20. As described above, theweight of the rig 20 can be manually input at the computer 705 ordetermined based on an evaluation of the lower limits of the rig loaddata 915 on the rig load data chart 905.

If the rig load is not above the predetermined level, the “NO” branch isfollowed to step 1525 to continue evaluation of the rig load data. Onthe other hand, if the rig load is above the predetermined level, the“YES” branch is followed to step 1535, where the computer 705 transmitsa signal to apply the brake and disengage the clutch for the hoist 36and block 38, thereby stopping any additional pulling of the tubing 62out of the wellbore 58. An alarm is initiated and an overload event isrecorded in step 1540 for subsequent analysis and training of the rigoperator. The alarm may be audible, visual or both. Audible alarmsinclude, but are not limited to, sirens, horns and the like. Visualalarms may include, but are not limited to, flashing lights, a lightturning on, or a display of a message at the computer 705. The processcontinues from step 1540 to the END step.

Although the invention is described with reference to preferredembodiments, it should be appreciated by those skilled in the art thatvarious modifications are well within the scope of the invention.Therefore, the scope of the invention is to be determined by referenceto the claims that follow. From the foregoing, it will be appreciatedthat an embodiment of the present invention overcomes the limitations ofthe prior art. Those skilled in the art will appreciate that the presentinvention is not limited to any specifically discussed application andthat the embodiments described herein are illustrative and notrestrictive. From the description of the exemplary embodiments,equivalents of the elements shown therein will suggest themselves tothose or ordinary skill in the art, and ways of constructing otherembodiments of the present invention will suggest themselves topractitioners of the art. Therefore, the scope of the present inventionis to be limited only by any claims that follow.

1-10. (canceled)
 11. A method for limiting block speed while pullingpipe from a well comprising the steps of: receiving load data comprisingthe load of a pipe string being removed from a well; computing anaverage load based on the load data; determining if the average load isbelow a predetermined level; and limiting block speed below apredetermined speed based on a positive determination that the averageload is below a predetermined level.
 12. The method of claim 11, whereincomputing the average load based on the load data comprises the stepsof: determining a start time for pulling a stand of the pipe from thewell; determining a completion time for pulling the stand of the pipefrom the well; removing a predetermined amount of the load data betweenthe start time and the completion time; and computing the average loadof the well service rig.
 13. The method of claim 12, further comprisingthe steps of: receiving a weight for the well service rig; and computinga hookload by calculating the difference between the average load andthe weight of the well service rig.
 14. The method of claim 12, whereincomputing the average load comprises calculating an average of theremaining load data that was not removed between the start time and thecompletion time.
 15. The method of claim 12, wherein removing apredetermined amount of the load data between the start time and thecompletion time further comprises: removing a first predetermined amountof the load data for a first predetermined amount of time beginning atthe start time; and removing a second predetermined amount of the loaddata for a second predetermined amount of time concluding at thecompletion time.
 16. The method of claim 15, wherein the first andsecond predetermined amounts of time are a predetermined percentage of adifference between the completion time and the start time. 17-25.(canceled)
 26. The method of claim 11, wherein the load data is receivedfrom at least one load sensor on a well service rig.
 27. The method ofclaim 11, wherein the predetermined speed is three feet per second. 28.The method of claim 11, wherein the predetermined load level is betweenfive and fifteen thousand pounds of hookload.
 29. The method of claim11, further comprising the step of increasing slippage in a transmissionfor a hoist, wherein the speed of the hoist controls the block speed.30. The method of claim 11, further comprising the step of reducing airpressure to a hoist clutch bladder.
 31. A method for limiting blockspeed while pulling pipe from a well comprising the steps of: receivingload data comprising the load of a pipe string being removed from awell; computing an average load based on the load data comprising thesteps of: removing a predetermined amount of the load data between astart time and a completion time; and computing the average load of awell service rig determining if the average load is below apredetermined level; and limiting block speed below a predeterminedspeed based on a positive determination that the average load is below apredetermined level.
 32. The method of claim 31, further comprising thesteps of: receiving a weight for the well service rig; and computing ahookload by calculating the difference between the average load and theweight of the well service rig.
 33. The method of claim 31, whereincomputing the average load comprises calculating an average of theremaining load data that was not removed between the start time and thecompletion time.
 34. The method of claim 31, wherein removing apredetermined amount of the load data between the start time and thecompletion time further comprises: removing a first predetermined amountof the load data for a first predetermined amount of time beginning atthe start time; and removing a second predetermined amount of the loaddata for a second predetermined amount of time concluding at thecompletion time.
 35. The method of claim 34, wherein the first andsecond predetermined amounts of time are a predetermined percentage of adifference between the completion time and the start time.
 36. Themethod of claim 31, wherein the load data is received from at least oneload sensor on a well service rig.
 37. The method of claim 31, whereinthe predetermined load level is between five and fifteen thousand poundsof hookload.
 38. The method of claim 31, further comprising the step ofincreasing slippage in a transmission for a hoist, wherein the speed ofthe hoist controls the block speed.
 39. The method of claim 31, furthercomprising the step of reducing air pressure to a hoist clutch bladder.